US 4751646 A Abstract For a formation zone of a well, a method for determining the relationship between bulk volume of oil φ
_{o} as a function of total effective formation porosity φ_{E} and height h above the oil water contact from capillary pressure data of a core taken from the formation of the well is disclosed. The disclosed relationship of the form,φ where C, K and g are constants derived from the capillary pressure data of the core and the relationship between h and the capillary pressure is affected by the relative densities of the connate water of the zone and the oil in the zone. In a well which has been produced and no φ
_{E} log exists, the original bulk volume of φ_{o} is determined from the R_{t} log in cooperation with the core data relationship between φ_{o}, φ_{E} and h through the relationship, ##EQU1##Claims(9) 1. A method for determining bulk volume of oil (BHO or φ
_{o}) as a function of depth and effective porosity in a zone of a produced well in which a log of effective porosity φ_{E} exists comprising the steps of:obtaining core samples from said zone corresponding to said zone of said produced well, testing said core samples to determine a first relationship of bulk volume of oil (BVO or φ _{o}) as a function of capillary pressure P_{c} and effective porosity φ_{E}, that is, φ_{o} =f(φ_{E}, P_{c}),determining the correspondence between capillary pressure, P _{c} and height h above the oil-free water contact of the zone of the form, ##EQU9## where d_{w} is the density of the connate water of the zone, d_{o} is the density of oil in the zone, and K_{1} is a constant of proportionality,determining a second relationship of bulk volume of oil (BVO) as a function of total porosity φ _{E} of the formation and height h above the oil water contact depth of the zone of the form,φ where C, K, and g are numerical constants, and recording a log of φ _{o} (h) from said second relationship by combining φ_{E} (h) data from a log of effective porosity for said zone.2. The method of claim 1 wherein the step of obtaining core samples comprises the sub steps of
forming a new well in the field in which said produced well is formed, and obtaining core samples from said new well in a zone corresponding to said zone of said produced well. 3. The method of claim 1 wherein
φ _{o} =f(φ_{E}, P_{c}) is a plurality of straight line approximations to measure data for various constant values of capillary pressure for the core, ##EQU10## and the step of determining the relationship, φ_{o} =Cφ_{E} -K+g log h comprises the sub steps of,determining average slopes and new intercepts for each of said straight line approximations to measured data, ##EQU11## and b _{1} ^{1} . . . b_{n} ^{1} are new intercept values where φ_{E} =0, anddetermining the relationship between said new intercept values b _{1} ^{1} ; P_{c} =C_{1} . . . b_{n} 1:P_{c} =C_{n} to said relationship between ##EQU12## of th form b_{n} ^{1} =-K+g log h.4. The method of claim 1 further comprising the step of determining the water saturation, S
_{w} (h) of the zone before production of oil from it by dividing φ_{w} (h) of the zone before production of oil from it by φ_{E} (h), that is, ##EQU13## and recording of S_{w} (h).5. The method of claim 4 further comprising the steps of determining the present water saturation S
_{wd} of a depleted zone from current logs of the zone, determining a recovery factor, ##EQU14## and recording said recovery factor as a function of depth in the zone.6. A method for determining bulk volume of oil φ
_{o} as a function of depth and original resistivity R_{t} in a zone of a produced well for which a resistivity log R_{t} as a function of depth exists but no effective porosity log as a function of depth exists comprising the steps of:obtaining core samples from said zone corresponding to said zone of said produced well, testing said core samples to determine a first relationship of bulk volume of oil (BVO or φ _{o}) as a function of capillary pressure P_{c} and effective porosity φ_{E}, that is, φ_{o} =f(φ_{E}, P_{c}),determining the correspondence between capillary pressure, P _{c} and height h above the oil-free water contact of the zone of the form, ##EQU15## where d_{w} is the density of the connate water of the zone, d_{o} is the density of oil in the zone, and K_{1} is a constant of proportionality,determining a second relationship of bulk volume of oil (BVO or φ _{o}) as a function of total porosity φ_{E} of the formation and height h above the oil water contact depth of the zone of the form,φ where C, K, and g are numerical constants, estimating the Bulk Volume of Water as a function of depth (BVW or φ _{w} (d)) for said zone as ##EQU16## where R_{w} is the resistivity of the connate water of the zone and n is an emperically derived constant,determining the original Bulk Volume of Oil of the zone in the produced well φ _{o} as a function of depth as ##EQU17## where the height h above the oil water contact point is matched to the depth of the corresponding to R_{t} (d), andrecording φ _{o} (h).7. The method of claim 6 further comprising the step of adding φ
_{w} (h) and φ_{o} (h) to derive a log of total porosity of the produced well as it was before production of oil from it, that is,φ and recording φ _{E} (h).8. The method of claim 7 further comprising the step of determining the water saturation, S
_{w} (h) of the zone before production of oil from it by dividing φ_{w} (h) of the zone before production of oil from it by φ_{E} (h), that is, ##EQU18## and recording of S_{w} (h).9. The method of claim 8 further comprising the steps of determining the present water saturation S
_{wd} of a depleted zone from current logs of the zone, determining a recovery factor, ##EQU19## and recording said recovery factor as a function of depth in the zone.Description 1. Field of the Invention This invention relates in general to a method for determining from core data the original bulk volume of oil as a function of effective porosity and height above the oil-water contact point for a well that has been in production. In particular the invention relates to a method for determining and recording as a function of depth, the original bulk volume of oil and saturations of a produced well using core data, and where an original porosity log does not exist, combining information from an original resistivity log to determine and record original bulk volume of oil and saturation. 2. Description of the Prior Art A paper by G. M. Heseldin entitled "A Method of Averaging Capillary Pressure Curves" published in the SPWLA Fifteenth Annual Logging Symposium, June 2-5, 1974 describes a method for determining an average capillary pressure curve for a particular rock type. Heseldin describes how capillary pressure data from a number of core samples of a zone of the formation can be measured and plotted with constant capillary curves P
(φ and then shows that the constants A and B are essentially linear with the logarithm of capillary pressure P A disadvantage of the Heseldin approach is that no single relationship is established by which the bulk volume of oil φ It is an object of the invention to provide a method for determining a single function by which bulk volume of oil φ It is another object of the invention to apply the determined bulk volume of oil φ The objects, advantages and features of the method are incorporated in a method for determining the bulk volume of oil as a function of depth and effective porosity in a zone of a produced well. The first step of the method is to obtain core samples from a zone corresponding to the zone of a produced well. Usually this step includes forming a test bore in proximity to the produced well and obtaining a plurality of cores from the zone corresponding to the pay zone in the produced well. The core samples are laboratory tested to determine the relationship of bulk volume of oil φ Next the relationship between capillary pressure P Next a second relationship of the form
φ is determined from the core data and the relationship between P Where a log of φ The objects, advantages and features of the invention will become more apparent by reference to the drawings which are appended hereto and wherein like numerals indicate like parts and wherein an illustrative embodiment of the invention is shown of which: FIG. 1 is a plan view of an oil field in which a number of producing oil wells have been formed with one test well also being formed in the field; FIG. 2 is a schematic illustration of a partial cross-section through the field showing a producing well through a pay zone and showing a test well through the pay zone in which core samples have been taken at varying depths through the zone; FIG. 3A is a flow-chart type illustration showing steps required to develop the relationship of bulk volume of oil φ FIG. 3B shows a typical set of laboratory capillary pressure curves for four core samples of varying porosity; FIG. 3C is a graph of porosity versus bulk volume of oil for various levels of capillary pressure of a producing oil field and FIG. 3D is a graph showing the relationship between the height above the oil-water contact of a pay zone and an "intercept" developed for the relationship between bulk volume of oil and capillary pressure and said height; FIG. 4 is an illustration of the use of an effective porosity log previously obtained in combination with the bulk volume of oil relationship determined according to the invention to produce on a log recorder a log of φ FIG. 5 illustrates a computer and log recorder with which the relationship determined from the steps of FIG. 3 is combined with an R Many major oil fields were brought on production without adequate information as to the correct hydrocarbon volume originally present. While most wells were logged by an electrical log or survey, porosity logs were not yet developed and sidewall coring gave questionable results. This invention relates to running modern well logs and performing special core analysis procedures to evaluate current and original bulk volume of oil and correlative oil saturation for each individual well in the field. FIG. 1 illustrates an oil field 10 in which produced wells 11-18 are shown and in which a test well 20 has been formed. FIG. 2 shows a cross-section through the formation pay zone 51 and illustrates old well 15 which has been cased, cemented and perforated by means of perforation 54. The oil-water contact level 52 is illustrated in pay zone 51 from which height h above that contact is measured and discussed in more detail below. The test well 20 is illustrated as extending through pay zone 51 and cores 22 are schematically illustrated as being taken from that zone. FIG. 3A shows that the method according to the invention includes performing capillary pressure tests on the cores which have a range of bulk volume of oil φ The functional relationship between φ Capillary pressure data for 17 levels for the 5800 foot sand of the Tom O'Connor Field in Texas were tabulated for four different pressures (1.0, 3.2, 6.2, & 10 psi). FIG. 3B illustrates the laboratory capillary pressure curves for four samples. Values of water saturation S
BVH=φ FIG. 3C is a graph created from the data of FIG. 3B but shows the porosity φ plotted versus bulk volume of oil for selected P Linear relations between φ and BVH for each P
______________________________________P FIG. 3C shows the plotted data for P The average slope for the BVH (or φ
______________________________________ (slope)(intercept)______________________________________P In this form, the intercept term (that is the numerical constants of each equation) varies with P When the in situ fluid densities d In the Tom O'Connor Field it is known that d It has been found that the intercept of each normalized equation is functionally related to h. FIG. 3D shows a plot of log h vs the normalized intercept. The trend line gives two pieces of data: The value of the intercept where log h=0 (h=1') and the slope of the trend. For this case the log h=0 value is -0.312 and the slope is 0.086. This relationship is inserted in the normalized equations to produce a single general equation:
BVH=1.467 φ In general therefore, the bulk volume of oil BVH or φ
φ Equation (1) is useful to assess original bulk volume of oil φ One of the problems facing a reservoir engineer is to obtain an appropriate recovery factor (RF) for a pay zone. The methods of this invention for developing a log of original water saturation S For example, the present water saturation of a water-drive depleted zone S For a given depleted zone, the RF may be plotted as a function of depth as illustrated in FIG. 4 as a log. The recovery factor may be applied to other wells in the field to provide better estimates for expected primary oil production. The RF log may be used to indicate whether or not actual production has met expected production. Also shown on the log of FIG. 4 is the typical SP log. The RF log helps to distinguish the productive oil sand from the depleted oil sand. For old wells however, porosity logs may not be available. If an original resistivity log exists for the well, it can be used to estimate bulk volume of oil and saturation that originally existed before production. It is known that the bulk volume of water, BVW or φ For said formations, n is usually from 1.8 to 2.0. Using the relationship,
φ equation (1) may be rearranged to the form, ##EQU8## FIG. 5 illustrates the case where R
S The computed logs φ Various modifications and alterations in the described structures will be apparent to those skilled in the art of the foregoing description which does not depart from the spirit of the invention. For this reason, these changes are desired to be included in the appended claims. The appended claims recite the only limitation to the present invention and the descriptive manner which is employed for setting forth the embodiments and is to be interpreted as illustrative and not limitative. Patent Citations
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